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Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004 4 ORi61NAI_ (202) 295-K.a85 I:^Cra'~Ol.~ (202) 424-7643 aun~xCa.?~,q m.aw.c:o~ -,qW DLER BERLIN SHEREFF FRIEDMAN, LLP ,L'~ THE WAsHn, to-wox t-Pau~ouit 30~0K~ , NW, SurrE300 WASHING'TON, DC 20007-5116 T ~ (202)424-7.500 FACSIMILE (202)424-7647 WWW.SWIDLAW,COM NEw gOgg Orn~ 'I~ Cxrest~. Btm.De~ 4051..~.~ OTOn A'cm, a~ ~ ' w YORK, NY 10174 1212) 973-0111 F.~C~a, OL~ ~212)891-9598 Dee, ember 20, 2004 Honorable Magalie R. Salas Secretary Federal Energy Regulatory Commission 888 First Street, N.E. Washington, D.C. 20426 t , (7,~ r.t ? "' "~" : ~ . ,~ . % ' ~ ?~ -- ~...,q ¢, ... GO Re: California IndependentSystem Operator Corporation. Docket No. ER01-313-004 Pacific Gas and Electric Company Docket No. ER01-424-004 Dear Secretary Salas: Enclosed please find an original and 7 copies of the Prepared Direct Testimony and Exhibits of A. Dearie Lyon on behalf of the California Independent System Operator Corporation. Two additional copies of this filing are enclosed to be stamped with the date and lime of filing and returned to our messenger. If there arc any questions concerning this filing, please contact the undersigned. Respectfully submitted, Ronald E. Minsk Counsel for the California Independent System Operator Corporation co: The Honorable Bobbie I, McCarmey Service List
Transcript

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

4

ORi61NAI_

(202) 295-K.a85 I:^Cra'~Ol.~ (202) 424-7643 aun~xCa.?~,q m.aw.c:o~

-,qW DLER BERLIN SHEREFF FRIEDMAN, LLP

,L '~ THE WAsHn, to-wox t-Pau~ouit 30~0 K ~ , NW, SurrE 300 WASHING'TON, DC 20007-5116

T ~ (202) 424-7.500 FACSIMILE (202) 424-7647

WWW.SWIDLAW,COM

NEw gOgg O r n ~ ' I ~ Cxres t~ . Btm.De~ 4051..~.~ OTOn A'cm, a ~

~ ' w YORK, NY 10174 1212) 973-0111

F.~C~a, OL~ ~212) 891-9598

Dee, ember 20, 2004

Honorable Magalie R. Salas Secretary Federal Energy Regulatory Commission 888 First Street, N.E. Washington, D.C. 20426

t , (7,~

r . t ? " ' " ~ " : ~ . ,~ . % ' ~

? ~ - - ~...,q ¢,

. . . G O

Re: California Independent System Operator Corporation. Docket No. ER01-313-004 Pacific Gas and Electric Company Docket No. ER01-424-004

Dear Secretary Salas:

Enclosed please find an original and 7 copies of the Prepared Direct Testimony and Exhibits of A. Dearie Lyon on behalf of the California Independent System Operator Corporation. Two additional copies of this filing are enclosed to be stamped with the date and lime of filing and returned to our messenger. If there arc any questions concerning this filing, please contact the undersigned.

Respectfully submitted,

Ronald E. Minsk

Counsel for the California Independent System Operator Corporation

co: The Honorable Bobbie I, McCarmey Service List

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

" ORIGINAL - - •

Summary of Testimony of A. ~ L y o n ~O on Behalf of the Catifomla Indepen(IQ(~Sl~, tern ,~

Operator Corporation ~7/: ,~>. , 9 . ~/r,b 0 ,. 0

A. Deane Lyon is manager of Operations Support at the C a l i ~ Independent

System Operator Corporation ("ISO"). His testimony addresses the manner and extent

to which behind-the-meter generation was included in the ISO's transmission and

operations planning studies between 2001 and 2003. His testimony also identif'ms the

relevant factors the iSO considers when modeling behind-the-meter generators in its

transmission and operations planning studies and how behind-the-meter load netted

against unmodeled generation impo~s control area services costs on the ISO.

Mr. Lyon's testimony initially defines behind4he-meter generation as situations in

which a Load's electrical consumption cannot be distinguished from a Generating Unit's

simultaneous production of electricity, because since both are measured with only one

meter. Mr. Lyon's testimony the presents the list of generators that the ISO modeled

between 2001 and 2003 which was prepared for the initial refund calculation in this

proceeding, and states that the ISO has not prepared a similar list for generators

modeled in 2004, No such list was prepared because the basis for calculating the Grid

Management charge has changed sufficiently. It is now allocated on a basis that does

not depend on the identification of the Generating Units that the ISO models, and the

ISO, therefore, does not maintain a list of the included Generating Units.

Mr. Lyon's testimony explains that the ISO adopts the powerfiow modeling of

generators from the Participating TOs and that the process for modeling generators is

the same, regardless whether the generator is "behind the meter" or not. He then

explains that for most Planning and Operations study cases, the Participating TOs - not

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

,?

the ISO - decide which generators to model when they provide their powerflow models

to the WECC and the ISO, and the ISO merely adopts that modeling representation.

Mr. Lyon's testimony summarizes the services provided by the ISO, the costs of

which were intended to be recovered by the control area services component of the

former GMC, and explains that there are certain services provided by the ISO from

which all loads and generation derive benefits, including behind-the-meter load. The

testimony also reiterates that there was not in 2001, and there currently is, no

exemption in WECC that permits excluding "load behind the meter" from a Control

Area's Load Responsibility. Mr. Lyon indicates that the ISO directly incurs costs for

behind-the-meter load in connection with all Control Area Services that are directed

toward ensuring that load continues to be served and that behind-the-meter load also

benef'ds, although less directly, from such activities as transmission planning,

maintenance, and outage coordination that ensure the existence of a robust

transmission network that can protect load in the case of the failure of behind-the-mater

generation. Mr. Lyon states that in order to meet its Control Area Operator reliability

obligations to the WECC, the ISO has the operational responsibility, operations

engineering and grid planning obligations to: 1) study and determine the impact to the

transmission system of such behind-the-meter loads and generators, 2) ensure that

local transmission facilities and substation equipment are designed and built such that

the interconnection of these loads and generators do not negatively impact that system,

and, 3) where necessary, modify local transmission facilities and substation equipment

to meet WECC planning and operating criteda for the Control Area in order to reliably

accommodate the new behind-the-meter loads and generators.

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

.~ dip

UNITED STATES OF AMERICA BEFORE THE

FEDERAL ENERGY REGULATORY COMMISSION

California Independent System Operator Corporation

Pacific Gas and Electric Company

) ) ) ) )

Docket Nos. ER01-313-000 ER01-313-001

Docket Nos. ER01-424-000 ER01-424-001

PREPARED DIRECT TESTIMONY OF A. DEANE LYON

ON BEHALF OF THE CALIFORNIA INDEPENDENT SYSTEM

OPERATOR CORPORATION

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

%" E.Xt). 180-H Page 1 of 15

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PLEASE STATE YOUR NAME, TITLE AND BUSINESS ADDRE88.

My name is A. Deane Lyon. ! am Director of Operations Support and Training

('OSAT") for the California Independent System Operator ('lSO'). My business

address is 151 Blue Ravine Road, Folsom, CA 95630.

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HAVE YOU PREVIOUSLY PROVIDED TESTIMONY IN A REGULATORY

PROCEEDING?

Yes I have. I provided testimony for the hearing that preceded the Initial

Decision in this docket. The Commission's Order establishing this proceeding

requests elaboration of the discussion of Control Area Services in my previous

testimony. I also provided testimony in Docket No. EL99-93-000, Turlock

Irrigab'on District v. California Independent System Operator Corporab'on,

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WHAT IS YOUR EDUCATIONAL BACKGROUND?

I am cert~sd by the California Apprenticeship Council as a System Operator.

Through May 19, 2004, I was a certified System Operator by the Western

Electricity Coordinating Council ('VVECC') and the North American Electric

Reliability Council ("NERC"). I attended Ohlone Junior College, Fremont,

California in 1976, taking business law, business administration and electronics

courses. Since being employed first with Pacific Gas and Electric Company

('PG&E') from December 1976 through September 1997 and from October 1997

with the California ISO, I have completed several system operations, supervisory

and management courses.

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

Exh. ISO-54 Page 2 of 15

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A.

PLEASE DESCRIBE YOUR WORK EXPERIENCE PRIOR TO THE

WORK YOU ARE DOING TODAY.

I began my professional career with PG&E in 1976 as a System Operator.

Through the course of my PG&E career, I worked as a System Operator at both

the distribution and transmission switching center levels, and supervised or

managed distribution and transmission switching canters, regional transmission

departments and a regional operator training program. I was an instructor at the

PG&E System Operator Training Center and Power System simulator. The last

seven years of my career with PG&E were spent in its Energy Control Center as

a Transmission Dispatcher, Interchange Scheduler, Generation Dispatcher and

Senior Operations Supervisor, in that order. As Senior Operations Supervisor, or

Shift Supervisor, I was responsible for the safe and reliable operation of the

PG&E Control Area grid which, prior to its incorporation into the ISO Control

Area, spanned from Bakersfield in the south to the California-Oregon border in

the north, and from the California coast to the California-Nevada border in the

east.

I joined the California ISO in October 1997 as a Shift Manager, assuming

the same responsibilities as I had at PG&E, but with a considerably larger

Control Area that includes most of the state of California, and with the added

market component. I moved from Grid Operations to the Operations Support and

Training department in late 1999 as an Operations Trainer. I became manager

of Operations Support in June 2000, and I became the Director, Operations

Support and Training in August 2001.

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Exh. ISO-54 Page 3 of 15

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WHAT ARE YOUR CURRENT RESPONSIBILITIES AT THE ISO?

I am currently Director of the Operations Support and Training Department at the

ISO. Personnel that report directly to me include managers for the following

groups: Operations Support, Operations Training, Operations Applications

Support and Operations Coordination. The primary role of OSAT is to provide

support to all departments within the Operations Division, including the

development of training programs, and support and development of tools for

operations. OSAT coordinates the Operations Division position on matters

affecting Operations and coordinates responses by Operations respondents to

market participant and legal inquiries. OSAT provides training and support to all

groups within the Operations Division, to other departments within the ISO, and

to Market Participants, to ensure and enhance system reliability as well as to

facilitate and expand workably competitive markets.

As the Director of OSAT, I am responsible for overseeing preparation and

administration of training across all operations groups, other groups in the ISO,

and Market Participants; providing support for ISO efforts to interface with and

incorporate markets and deregulation from an operations perspective as they

develop inside and outside the ISO; updating, creating and maintaining all ISO

Operating Procedures; implementing emergency response programs and

procedures within the ISO and in coordination with state and federal agencies;

providing presentation development and support for the Operations organization;

reviewing ISO Tariff changes, legislation, and regional and national operating

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

Exh. ISO-54 Page 4 of 15

organization polices from an operations feasibility point-of-view; and for providing

budget development and support for the Operations Division.

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AS YOU TESTIFY, WILL YOU BE USING ANY SPECIALIZED TERMS?

Yes, I will usa capitalized terms as defined in the Master Definitions Supplement,

Appendix A of the ISO Tariff.

6 Q, WHAT IS THE PURPOSE OF YOUR TESTIMONY?

7 A. The purpose of my testimony is to provide information in response to issues

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identified by the Commission in its November 16, 2004, Order initiating this

proceeding. Those issues are the following:

. The manner and extent to which behind-the-meter generation was included during the time period at issue in the ISO's transmission and operations planning studies, including a listing of generators that ware explicitly modeled in these studies. Additionally, the Commission also asked for the same information for 2004.

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. All relevant factors the ISO has considered when modeling behind-the-meter generators in its transmission and operations planning studies, including: (1) WECC requirements for modeling; (2) the generator size and location on the transmission and/or distribt¢don system; (3) load associated with that generation; (4) voltage, stability, and short-circuit concerns; and (5) the impact of the generator on the transmission system.

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. How and to what extent behind-the-meter load netted against unmodeled generation imposes CAS costs, as delineated by ISO witness Lyon, on the ISO.

24 4. What regulatory controls (if any) are necessary for the ISO to report which 25 generation and associated load it does not model.

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

Exh. ISO-54 Page 5 of 15

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Q.

A.

DO YOU UNDERSTAND THE TERM "BEHIND-THE-METER

GENERATION" AS IT IS USED BY THE COMMISSION IN ITS ORDER

OF NOVEMBER 18, 2004?

Yes. The term "behind-the-meter" generally refers to situations in which a

Load's electrical consumption cannot be distinguished from a Generating Unit's

simultaneous production of electricity, because both are measured with only one

meter. This is the manner in which I used the term in my previous testimony and

the manner in which I understand the Commission to have used it in the

November 16 Order. This definition of behind-the-meter holds true no matter

what type of entity is generating power behind the meter, including municipal

utility generators, QFs, and any other entity that might be generating power.

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Q. IN THE NOVEMBER 16 ORDER, THE COMMISSION INDICATED THAT

IT WANTED INFORMATION ABOUT THE MANNER AND EXTENT TO

WHICH BEHIND-THE-METER GENERATION WAS INCLUDED DURING

THE TIME PERIOD AT ISSUE IN THE ISO'S TRANSMISSION AND

OPERATIONS PLANNING STUDIES, INCLUDING A USTING OF

GENERATORS THAT WERE EXPLICITLY MODELED IN THESE

STUDIES. PLEASE IDENTIFY THE GENERATORS THAT THE ISO

MODELED AS PART OF ITS TRANSMISSION AND OPERATIONS

PLANNING STUDIES BETWEEN JANUARY I , 2001 AND DECEMBER

31, 2003.

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004 .

"" Exh. ISO-54 Page 6 of 15

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A. Exhibit ISO-37 is a list of the generators that the ISO modeled as part of its

transmission and operations planning studies between January 1, 2001 and

December 31, 2003. This list was previously prepared in order to comply with

the Commission's January 23, 2004 rehearing order in this proceeding, and was

used to identify the generators with unmodeled behind-the-meter load, so that

the ISO could undertake the calculations necessary for the compliance filing of

the ISO in this proceeding, which was filed on November 15, 2004 and rendered

moot by the Commission's Order issued the following day. The list was not

included as part of the submission to the Commission. I did not prepare that

filing.

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Q.

A.

THE COMMISSION ALSO ASKED FOR INFORMATION REGARDING

THE GENERATORS THAT THE ISO MODELED AS PART OF ITS

TRANSMISSION AND OPERATIONS PLANNING STUDIES SINCE

JANUARY 1, 2004. DO YOU HAVE SUCH INFORMATION AT THIS

TIME?

No. As I will discuss later in my testimony, the ISO adopts powerflow models

from the Partic/pating Transmission Owners (Participating TO's), who identify the

Generating Units to be included. It is not necessary for the ISO to maintain a list

of the included Generating Units. The list of generators for the compliance filing

was prepared specifically for that purpose. Because the Grid Management

charge is now allocated on a basis that does not depend on the identification of

the Generating Units that the ISO models, the ISO does not have a list for 2004.

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"" Exh. ISO-54 Page 7 of 15

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Q. IN ADDITION TO ASKING ABOUT THE MANNER IN WHICH ISO

INCLUDES THE MODELING OF BEHIND-THE-METER GENERATION IN

THE ISO'S TRANSMISSION AND OPERATIONS PLANNING STUDIES,

THE COMMISSION INQUIRED ABOUT RELEVANT FACTORS THE ISO

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A.

HAS CONSIDERED WHEN MODELING BEHIND-THE-METER

GENERATORS IN ITS TRANSMISSION AND OPERATIONS PLANNING

STUDIES. PLEASE EXPLAIN THE ROLE OF GENERATION

MODELING, INCLUDING BEHIND-THE-METER GENERATION, IN THE

ISO'S TRANSMISSION AND OPERATIONS PLANNING.

In order to discharge all of its WECC functions, the ISO models such generation

not only for Grid Planning, but also, along with the other generation in the Control

Area, for operational engineering and other operations responsibilities. For

example, the ISO and its Participating TO must include all behind-the-meter

generation and associated load in operating and planning studies when:

The behind-the-meter generation may deliver excess Energy to the grid in the wholesale market arena, either on a regular and routine basis, or intermittently at various times throughout the year.

The behind-the-mater load served by the behind-the-meter generation would remain connected and continue to draw power from the transmission grid in the event the behind-the-meter generation tripped or was curtailed (i.e., for facilities that have a standby service agreement with the UDC).

The behind-the-meter generation is of such size, nature, and character and connected at a critical point within the transmission system such that the generation could have a pronounced and significant effect on the transient or dynamic performance of the transmission system including, but not limited to:

2g ~ transient stability,

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o." Exh. ISO-54 Page 8 of 15

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voltage collapse, local area power quality, fault current contribution, coordination of protective devices.

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A.

PLEASE EXPLAIN THE ISO'S PROCESS FOR MODELING A

GENERATOR IN ITS TRANSMISSION AND OPERATIONS AND

PLANNING STUDY CASES.

The ISO adopts the power flow modeling of generators from the Participating

TOs. For existing units, the generator models are embedded in power flow

cases the ISO routinely receives from Participating TOs or the WECC through

various Planning and Operating study forums. For proposed and newly

constructed units, the ISO receives power flow model "change files" from the

Participating TO where the unit will be connecting. These incremental modeling

changes are then applied to the ISO's current resident Planning and Operating

study cases, where appropriate.

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A.

DOES THE MODEUNG PROCESS VARY FROM GENERATOR TO

GENERATOR? FOR A BEHIND-THEJ~ETER GENERATOR AS

OPPOSED TO ONE THAT IS NOT BEHIND-THE~METER, FOR

EXAMPLE? IF SO, PLEASE OESCRIBE THE REASON THAT, AND

THE MANNER IN WHICH, THE PROCESS MIGHT VARY BETWEEN

GENERATORS.

For most Planning and Operations study cases, the process for modeling

generators is the same, regardless whether the generator is behind-the-meter or

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Exh. ISO-54 Page 9 of 15

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not. In some specialized uses of the power flow model (Energy Management

System's (EMS) and the Market Model power flow), the ISO changes the

detailed, gross representation of behind-the-meter generation and load to an

equivalent ('netted') model.

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A.

HOW DOES THE ISO DECIDE WHICH GENERATORS TO MODEL AND

WHICH GENERATORS NOT TO MODEL?

For most Planning and Operations study cases, the Participating TOs - not the

ISO - decide which generators to model when they provide their powerflow

models to the WECC and the ISO; the ISO adopts and preserves that modeling

representation. The ISO only changes generator models in the previously

described specialized circumstances, when the nature of the associated

information system (EMS telemetry, or the appropriate granularity for Market

Scheduling) necessitates changing it.

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Q.

A.

PLEASE EXPLAIN WHAT YOU UNDERSTAND TO BE THE MEANING

OF 'NETTING LOAD,' AS USED BY THE COMMISSION IN THE

NOVEMBER 16 ORDER.

In the context provided by the Commission's November 16 Order in this

proceeding, I understand the term to mean the metered value at the point of

delivery, which generally is the netted value of the behind-the-meter load and

generation. For example if a behind-the-rneter generator is producing 20 MW

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

"" Exh ISO-54 Page 10 of 15

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and the behind-the-meter load in that same location is consuming 10 MW, the

metered value at the point of delivery would be 10 MW

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A.

PLEASE SUMMARIZE THE SERVICES PROVIDED BY THE ISO, THE

COSTS OF WHICH WERE INTENDED TO BE RECOVERED BY THE

CONTROL AREA SERVICES COMPONENT OF THE FORMER GMC.

The ISO is charged with ensuring the safe, reliable operation of the Control Area,

including the dispatch of bulk power supplies in accordance with NERC and

WECC (formerly WSCC) standards It is therefore the ISO's responsibility,

subject to monetary penalty, to ensure that it provides system balancing and to

arrange for adequate Operating Reserves for ALL Loads within the ISO Control

Area, which include those Loads sewed by on-site Generation interconnected

and synchronized to the ISO Controlled Grid and capable of drawing Energy in

the event of an on-site Outage of Generation The physics of a transmission grid

require that a system operator must constantly monitor, in real time. what is

happening to the entire transmission grid to maintain the reliability and safety of

the system. While the actual Energy used to balance Generation and Load is not

itself an element of CAS, the monitoring efforts by the ISO to ensure the safe and

reliable operation of the ISO Control Area, and the administrative costs of

dispatching of the Energy to balance Generation and Load are a part of the CAS

component.

The ISO, as Control Area operator, performs numerous administrative

functions beyond the moment-to-moment monitoring and operation of the ISO

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Controlled Grid and real-time delivery of Energy requirements. A non-

comprehensive listing of these functions includes:

• Determination of mat-time resource adequacy • Dispatching of resources in order to balance Load and resources in

real time • Procurement and maintenance of the required amount of Operating

Reserve • Coordination of Western Interconnection reliability with WECC

reliability coordinators • Integration and coordination with other control areas • Interchange scheduling • Existing Transmission Contracts scheduling and administration • Development, maintenance and monitoring of the EMS and associated

telemetry • Day-ahead/Hour-ahead intertie scheduling • Reconciliation of schedules post real-time • NERC, WECC, and ISO Tariff required reporting • Coordination of transmission and generation outages • Development, monitoring and enforcement of transmission

maintenance standards • Management and oversight of generation interconnection • Performance of seasonal, annual and special analyses of transmission

system performance and ratings • Performance of transmission planning to ensure overall system

reliability, performance of reserve requirement studies, load forecasting and long term transmission resource adequacy

• Coordination of participation in regional organizations, such as WECC, NERC, and NAES8

• Determination of Long Term Generation adequacy • Determination of Reliability Must Run requirements

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A.

DOES THE ISO PROVIDE THESE SERVICES FOR ALL LOAD,

INCLUDING BEHIND-THE-METER LOAD? FOR EXAMPLE, DOES THE

ISO UNDERTAKE TRANSMISSION PLANNING ACTIVITIES TO

SUPPORT BEHIND-THE-METER LOAD?

There are certain services provided by the ISO from which all loads and

generation derive benefits. As I allude to above, and elaborate upon here. the

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ISO, as a Control Area Operator, is obligated by WECC criteria and NERC policy

to provide its proportionate share of frequency control to the Western

Interconnection, to control and manage voltage within the ISO Control Area and

to balance resources with load, including maintaining a required amount of

operating reserve, such that the ISO Control Area is not a burden to the other

Control Areas and non-Control Area entities that comprise the Western

Interconnection. The ISO Grid Planning process incorporates transmission

assessments performed by Participating Transmission Owners to develop

transmission expansion plans for the ISO Controlled Grid. These studies include

transmission adequacy analyses during generation outage conditions that require

the transmission system to serve load that can no longer be served by local

generation because the local generation is unavailable.

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Q.

A.

ARE BEHIND-THE-METER LOADS A PART OF THE ISO'S LOAD

RESPONSIBILITY FOR THE ISO CONTROL AREA?

Yes, when the behind-the-meter load served by the behind-the-meter generation

remains connected and continues to draw power from the transmission grid in

the event the behind-the-meter generation trips, that is, disconnects from the

grid. The ISO therefore needs to have reserves available to serve the load if the

behind-the-meter generation trips. There was not in 2001 and there currently is

no exemption in WECC that permits excluding load behind the meter from a

Control Area's Load Responsibility. As was discussed during the previous

hearing on this docket, there has been some discussion regarding revisions of

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the WECC requirements to exclude behind-the-meter retail load with standby

service from a Control Area's Responsibility, but that has not occurred and

certainly does not affect the period at issue in this proceeding.

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Q.

A.

IN RESPONSE TO THE COMMISSION'S INQUIRY, CAN YOU IDENTIFY

THE AREAS IN WHICH THE ISO INCURS COSTS TO MEET ITS

RESPONSIBILITIES WITH RESPECT TO BEHIND-THE-METER LOAO

(I.E., BEHINO-THE-METER LOAD NETTED AGAINST UNMODELED

GENERATION)?

The (SO acknowledged in 2001 GMC that it hoped in later filings to allocate the

Grid Management Charge with a greater degree of granularity, and indeed has

done so. From my perspective as a former System Operator, the Control Area

Services category in the 2001 GMC filing is not easily amenable to further

specific subdivisions. The most important factor is that the WECC does not

distinguish between load behind-the-meter and any other load. Therefore the

ISO directly incurs costs for behind-the-meter load in connection with all Control

Area Services that are directed toward ensuring that load continues to be sewed.

These costs would include the maintenance of voltage control; frequency control;

and Operations Engineering and Planning functions to determine the impact of

the behind-the-meter load or generator when connected to and disconnected

from the gdd, To the extent the behind-the-meter load has not self-provided or

made appropriate arrangements (for example though an adequate standby

service arrangement) for the required amount of operating reserve, the ISO must

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

Exh. ISO-54 Page 14 of 15

1

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6

be prepared to maintain continuity of service to such load, and, therefore, must

procure the required amount of operating reserve. Behind-the-meter load also

beneFds, although less directly, from such activities as transmission planning,

maintenance, and outage coordination that ensure the existence of a robust

transmission network that can protect load in the case of the failure of behind-

the-meter generation.

7

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Q.

A.

WHY MUST THE ISO PROVIDE SUCH SERVICES FOR BEHIND-THE-

METER LOAD? WHY IS IT ESSENTIAL THAT THE ISO HAVE

COMPREHENSIVE INFORMATION ABOUT BEHIND-THE-METER

LOAD IN ORDER TO MANAGE THE GRID?

Simply stated, in order to meet its Control Area Operator reliability obligations to

the WECC. The ISO has the operational responsibility, operations engineering

and grid planning obligations to: 1) study and determine the impact to the

transmission system of such behind-the-meter loads and generators, 2) ensure

that local transmission facilities and substation equipment are designed and built

such that the interconnection of these loads and generators does not negatively

impact that system, e.g., that this new equipment does not exceed existing

substation circuit breaker fault duties and that protective relays are properly

coordinated, 3) where necessary, modify local transmission facilities and

substation equipment to meet WECC planning and operating criteda for the

Control Area in order to reliably accommodate the new behind-the-meter loads

and generators.

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

Exh. ISO-54 Page 15 of 15

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Q.

A.

DOES THE ISO NEED INFORMATION THAT IT DOES NOT HAVE, IN

ORDER TO REPORT WHICH GENERATORS ANO WHAT

ASSOCIATED LOAO THE ISO DOES NOT MODEL?

It is my understanding that this fact finding proceeding by the Commission relates

to the Commissions' orders in Opinion No. 463-A. Specifically it refers to the

liability of behind-the-meter generation for the Control Area Services component

of the then Grid Management Charge. Because the ISO no longer estimates

behind-the-meter load for the purposes of assessing Control Area Services (or its

current equivalent) and that the relevant entities remaining within the Control

Area now comply with the ISO's requirements, regulatory controls through which

the Commission directs parties to provide information to the ISO so that it may

accurately charge behind-the-meter load are not required.

As to whether or not there is additional information that the Commission

might assist the ISO in obtaining, the answer is yes there is. However, I am

unsure whether, given the earlier part of my answer and the restricted nature of

this proceeding, this is the place to seek such assistance.

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

EXHIBIT IS0-55

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Callfomia ISO Docket NOS. ER01-313-004 et al.

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Exh. ISO-55 Page 2 of 18

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

California ISO Docket Nos. ER01-313-004 eta/.

SCE 24703 BLM E7G 13.8 7 20 SCE 24704 BLM E8G 13.8 8 20 SCE 24705 BLM WgG 13.8 g 20 SCE 24708 E3ORAX I 13.8 I 47 SCE 24456 BOREL 66 1 0 SCE 2802~ BRDWAYB3 13.8 C1 0 SCE 2440a BREEZE 66 1 0 SCE 28506 BREEZE1 12 1 0 SCE 28507 BREEZE2 12 1 0 SCE 24018 BRIGEN 13.8 1 0 SCE 2470~ BSPHYD26 2.2 26 12 SCE 2471(] BSPHYD34 2.2 34 14 SCE 25634 B U C ~ D 115 1 0 SCE 28280 ~,BAZON 34.5 1 0 SCE 24711 3ALGENIG 13.8 1 30 SCE 24712 3ALGEN2G 13.8 2 25 SCE 24713 ~ALGEN3G 13.8 3 25 SCE 25633 ~APWtND 115 1 0 SCE 24020 CARBOGEN 13.8 1 34 SCE 28007 CENTURY 12.47 1 7.25 SCE 28007 CENTURY 12.47 2 7.25 SCE 28007 CENTURY 12.47 3 7.25 SCE 28007 CENTURY 12,47 4 7.25 SCE 2419g CHEVMA]N 86 1 76 SCE 24028 ~IMGEN 13.8 1 30 ;CE 24027 3OLDGEN 13.8 1 0 ;CE 28022 3PC-COLT 12 1 0

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Exh. ISO-55 Page 3 of 18

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

California 1SO Docket Nos. ER01-313-004 et aL

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Exh. ISO-55 Page 4 of 18

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

California ISO Docket Nos. ER01-313-004 et al.

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Exh ISO-55 Page 5 of 18

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Exh. 150-55 Page 7 of 18

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

California ISO Dodxet Nos. ER01-313-004 et aL

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Exh. ISO-55 Page 8 of 18

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Exh ISO-55 Page 12 of 18

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;)G&E 38120 LODI25CT PC-&E 31900 GRIZZLYG PG&E 38860 CSCGNRA1 ~G&E 36859 CSCGNRA2 ~G&E 38114 STIG CC ~G&E 31435 GEO.ENGY PG&E 31435 GEO.ENGY PG&E 36906 W1N.-AMED F'G&E 36906 W1N-AMED PG&E 31846 COVE RD PG&E 31848 COVE..RD PG&E 31848 COVE ,,,RD ~G&E 31846 COVE=RD PG&E 31162 LOW GAP PG&E 31164 BLUFORD PC-&E 31166 KEKAWAK PG&E 3143( INDIAN V PG&E 31168 V~r~A BAKR PG&E 31554 GROUSCRK PG&E 31583 LEV~STON PG&E 31855 OLSEN PC-,&E 31590 CEDR CRK PG&E 31858 BAILEY+2 PG&E 31858 BNLEY+2 PG&E 31858 BAILEY+2 PG&E 31862 DEADWOOD PG&E 31475 KANAKA PG&E 31868 HATLOST+ PG&E 31868 HATLOST+ PG&E 31868 HATLOST+ PG&E 31870 FORK.BUTT ;'G&IE 31870 FORKBUTr PG&E 32488 HAYPRES+ PG&E 32488 HAYPRES+ IaG&E 31591 COWCREEK PG&E 33901 PHOENIX I=G&E 32375 BONNIE N ~G&E 33505 MURPHYS I:)G&E 31705 CLARK RD PG&E 31705 CLARK RD PG&E 33505 MURPHYS PG&E 31587 BEAR CRK PG&E 31872 CLOVER PG&E 34838 FRtANTDM PG&E 35020 RIOBRAVO PC-&E 31874 SPI-BURN I:~-&E 31876 BIG VLLY PG&E 31880 SPI-HAYF PG&E 31884 :'AC.ENGY PG&E 32490 GRNLEAFI PG&E 32492 GRNLEAF2 PG&E 32494 CUBA CTY

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Exh. ISO-55 Page 14 of 18

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

California tSO Docket No~. ER01-313-004 et af.

PG&E 32154 WADHAM PG&E 31888 OROENGY PG&E 31890 PO POWER PG&E 31890 PO POWER PG&E 36908 JELD-WEN PG&E 31892 PE.WWOOD PG&E 36910 HONEYLAK PG&E 36910 HONEYLAK PG&E 31894 COLLINS PG&E 31896 SPI-QUCY PG&E 31896 SPI-QUCY PG&E 32156 WOODLAND PG&E 32498 SPILINCF PG&E 32500 ULTR RCK PG&E 33826 MARTELL PG&E 33830 'GENMILL PG&E 31446 SONMA LF PG&E 33151 FOSTER W PG&E 33151 IFOSTER W PG&E 33151 FOSTER W PG&E 33466 tUNTED CO PG&E 33488 SRI INTL PG&E 32738 OLS PG&E 33160 DOW CHEM PG&E 33133 GWF #3 PG&E 33145 CROWNZ. PG&E 32920 UNION CH PG&E 33139 STAUFER PG&E 33131 ,GWF #1 F)G&E 33135 GWF ~G&E 35860 'OLS-AGNE ~G&E 36856 CSC CCA ~G&E 35863 CATALYST PG&E 34332 JRWCOGEN PG&E 34334 BIO PWR PG&E 33483 CARDINAL PG&E 36418 ST MARIA PG&E 34840 ULTR.I:~N~ PG&E 34842 KINGSBUR

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Exh. ISO-55 Page 15 of 18

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

California ISO Docket Nos. ER01-313-004 et aL

PG&E 34783 TEXCO_NM PG&E 3478~ TEX MCKT PG&E 3503~ MT POSO PG&E 34757 UNIVRSTY PG&E 3503~ CHALKCLF PG&E 3504C KERNRDGE PG&E 350441TX MIDST PG&E 3804~ SHL-KERN PG&E 3504~ FRITOLAY PG&E 3505(: SLR-TANN PG&E 35052 CHEV.USA PG&E 350581PSE-LVOK PG&E 350~ PSEMCKIT PG&E 350~ DISCOVRY PG&E 35064, NAVY 35R PG&E 35064 NAVY 35R PG&E 33136' CCCSD PG&E 35066 PSE-BEAR PG&E 32165: USW1NDPW PG&E 32168 USWINDPW PG&E 30570 USWP-RLF PG&E 30575 WND MSTR PG&E 33175 ALTAMONT PG&E 33175 ALTAMONT PG&E 33838 USWP=#3 PG&E 33840 FLOWD3-6 PG&E 33171 NE&HOWO PG&E 30655 ADCC PG&E 35312 SEAWESTF PG&E 35314 WALKER+ PG&E 35316 ZOND SYS PG&E 35208 USWI:LFRK PG&E 35318 FLOWDPTR PG&E 33576 USWP-PAT PG&'E 33576 USWP-PAT PG&E 33576 USWP-PAT PG&E 33576 USWP-PAT PG&E 33579 FAYETTE PG&E 33578 FAYETTE PG&E 33578 FAYETI'E PG&E 33578 FAYETI'E PG&E 34342 INT.TURB PG&E 37549 FOLSOMI PG&E 37550 FOL$OM2 PG&E 37551 FOLSOM3 PG&E 37553 J.F.CARR PG&E 37553 J.F.CARR PG&E 37645 NIMBUS12 PG&E 37645 N(MBUS12 PG&E 37561 MELONE1 PC-&E 37562 MELONE2 PG&E 37575 SHASTA1

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California ISO Docket Nos. ER01-313-004 et al.

PG&E 34539 GWF GT1 13.8 1 49 PG&E 34541 GV~ GT2 13.8 1 49 PG&E 34186 DG PAN1 13.8 1 49 PG&E 32963 GROYPKR1 13.8 1 48.7 PG&E 32964 GROYPKR2 13.8 2 48.7 PG&E 32965 GROYPKR3 13.8 3 48.7 PG&E 31154 HUMBOLDT 13.2 1 15 PG&E 31154 HUMBOLDT 13.2 2 15 PG&E 31400 SANTAFE 13.8 2 32.1 PG&E 38556 WALNUT1 13.8 1 0 PG&E 38558 WALN UT2 13.8 1 0 F~3;&E 30464 EXXON,. BH 12.47 1 52 PG&E 35009 SUNSETG2 13.8 2 75 PG&E 35010 SUNSETG3 13.8 3 75 PG&E 35035 ULTRAOGL 13.8 1 34.47 PG&E 35078 ELKHIL3G 18 1 SMUD OWN 225.5 PG&E 35077 ELKHIL2G 18 1 SMUD OWN 166.8 PG&E 35076 ELKHIL1G 18 1 SMUD OWN 166.8 PG&E 36202 BAF COG1 13.8 1 38 PG&E 36203 BAF COG2 13.8 1 75 ~G&E PTSB 1 PG&E PTSB 2 PG&E PTSB 3 PG&E PTSB 4 PG&E FMC CT PG&E 33687 SCE 24120 SCE 24149 PG&E 33918 PG&E 31451

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Exh. IS0-55 Page 18 of 18

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

UNITED STATES OF AMERICA BEFORE THE

FEDERAL ENERGY REGULATORY COMMISSION

California Independent System Operator Corporation

Pacific Gas and Electric Company

Docket No. E R01-313-004

Docket No. ER01-424-004

DECLARATION OF WITNESS

I, Deane Lyon, declare under penalty of perjury that the statements contained in

the Prepared Direct Testimony on behalf of the California Independent System

Operator Corporation in this proceeding are true and correct to the best of my

knowledge, information, and belief.

Executed on this 17th day of December, 2004.

Deane Lyon

Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004

CERTI~CATE OF SERVICE

I hereby certify that I have this day served a copy of this document upon all parties limed on the

official service list compiled by the Secretary in the above-captioned proceedings, in accordance with the

requirements of Rule 2010 of the Commission's Rules of Practice and Procedure (18 C.F.R. § 385.2010).

Dated this 20 ~h day of December in the year 2004 at Folsom in the State of California.

Stephen A.S. Morrison


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